Plug and play connection system for a below-tension-ring managed pressure drilling system

ABSTRACT

A connection system for a managed pressure drilling system includes a connection hub flange that includes a plurality of pass-through ports and a plurality of connection hub flange ports. A connection hub ring is removably disposed around an outer surface of the connection hub flange. The connection hub ring includes a plurality of dogs configured to removably attach the connection hub ring to the outer surface of the connection hub flange and a plurality of stab-in connectors disposed around an outer surface of the connection hub ring. A ported bottom includes a plurality of bottom flange ports. A plurality of conduits connects the plurality of connection hub flange ports to the plurality of bottom flange ports. The plurality of stab-in connectors are connected to the plurality of connection hub flange ports by the plurality of pass-through ports.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. patent application Ser. No.16/130,263, filed Sep. 13, 2018, which claims the benefit of, orpriority to, U.S. Provisional Patent Application Ser. No. 62/640,128,filed on Mar. 8, 2018, both of which are hereby incorporated byreference in their entirety.

BACKGROUND OF THE INVENTION

Conventional open-loop hydraulic drilling systems manage bottomholepressure (“BHP”) by adjusting the equivalent circulating density (“ECD”)of the fluids, sometimes referred to as mud, disposed within thewellbore. The ECD is the effective fluid density exerted by acirculating fluid against the formation that takes into account thecirculating frictional pressure on the fluids returning to the surfaceand is a function of the injection rate of the mud pumps, the propertiesof the injected fluids, and the true vertical depth of the wellbore.Under static conditions, when circulation is suspended, circulatingfrictional pressure is lost and the BHP tends to drop. In narrowpressure windows, this drop may cause the BHP to fall below the porepressure, potentially inducing a kick, or unintentional influx offormation fluids, into the wellbore. In such circumstances, to prevent akick, heavier mud weight fluids may be used to maintain the BHP at apressure higher than that of the pore pressure of the formation. Assuch, the driller must pay careful attention to the ECD and pressureprofile of the wellbore during all drilling operations includingdrilling, making connections, and tripping into and out of the hole.

In contrast, closed-loop hydraulic drilling systems manage BHP byadjusting the choke settings of a choke manifold, typically disposed ona platform of the floating drilling rig, as part of a pressurized fluidreturn system. A rotating control device, active control device, orother annular sealing system seals the annulus surrounding the drillstring or drill pipe and returning fluids are diverted to the chokemanifold. Because the annulus is sealed pressure tight, surfacebackpressure may be applied and controlled by adjusting the chokesettings of the choke manifold. Under static conditions, when drillingceases, surface backpressure may be provided by the choke manifold,instead of using fluids with heavier mud weights, to maintain the BHPabove the pore pressure of the formation. In addition to preventingkicks, and alleviating a number of pressure related drilling problems,the closed annular system with pressurized fluid returns, sometimesreferred to generally as a managed pressure drilling (“MPD”) system,allows for the accurate control of annular pressure during all drillingoperations including drilling, making connections, and tripping into andout of the hole, as well as completions.

BRIEF SUMMARY OF THE INVENTION

According to one aspect of one or more embodiments of the presentinvention, a plug and play connection system for a managed pressuredrilling system includes a connection hub flange disposed around anouter surface of an outer barrel of a telescopic joint that includes aplurality of pass-through ports and a plurality of connection hub flangeports. A connection hub ring is removably disposed around an outersurface of the connection hub flange. The connection hub ring includes aplurality of dogs configured to removably attach the connection hub ringto the outer surface of the connection hub flange and a plurality ofstab-in connectors disposed around an outer surface of the connectionhub ring. A ported bottom flange is connected to a bottom distal end ofthe outer barrel of the telescopic joint and includes a plurality ofbottom flange ports. A plurality of conduits connect the plurality ofconnection hub flange ports to the plurality of bottom flange ports. Theplurality of stab-in connectors are connected to the plurality ofconnection hub flange ports by the plurality of pass-through ports.

According to one aspect of one or more embodiments of the presentinvention, a plug and play connection system riser joint for a managedpressure drilling system includes an inner barrel having an inner barrelcentral lumen and an outer barrel having an outer barrel central lumen.The inner barrel is configured to reciprocate within the outer barreland the inner barrel central lumen is in fluid communication with theouter barrel central lumen. A packer is disposed at a top distal end ofthe outer barrel and is configured to seal an annulus between the innerbarrel and the outer barrel as the inner barrel reciprocates. A tensionring is configured to support the packer. A connection hub flange isdisposed around an outer surface of the outer barrel and includes aplurality of pass-through ports and a plurality of hub flange ports. Aconnection hub ring is removably disposed around an outer surface of theconnection hub flange and includes a plurality of dogs configured toremovably attach the connection hub ring to the outer surface of theconnection hub flange and a plurality of stab-in connectors disposedaround an outer surface of the connection hub ring. A bearing ring isconfigured to movably attach the connection hub ring to the tensionring. A ported bottom flange is connected to the bottom distal end ofthe outer barrel and includes a plurality of bottom flange ports. Aplurality of conduits connect the plurality of connection hub flangeports to the plurality of bottom flange ports. The plurality of stab-inconnectors are connected to the plurality of connection hub flange portsby the plurality of pass-through ports.

According to one aspect of one or more embodiments of the presentinvention, a method of retrofitting a managed pressure drilling systemfor use with a plug and play connection system includes attaching aconnection hub flange to an outer barrel of a telescopic joint,attaching a ported bottom flange to a bottom portion of the telescopicjoint, connecting a plurality of hub flange ports of the connection hubflange to a plurality of bottom flange ports of the ported bottom flangewith a plurality of conduits, attaching a first side of a bearing ringto a bottom side of a tension ring, attaching a second side of thebearing ring to a top side of a connection hub ring, disposing thetension ring, bearing ring, and connection hub ring around thetelescopic joint below a packer of the telescopic joint, connecting aplurality of drape hoses that connect a plurality of stab-in connectorsof the connection hub ring to equipment disposed on a platform of thefloating drilling rig, and actuating the plurality of stab-inconnectors.

Other aspects of the present invention will be apparent from thefollowing description and claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 shows an upper marine riser system of a conventional open-loophydraulic drilling system.

FIG. 2 shows an upper marine riser system of a conventionalbelow-tension-ring closed-loop hydraulic drilling system.

FIG. 3A shows a cross-sectional view of a plug and play connectionsystem for a managed pressure drilling system in accordance with one ormore embodiments of the present invention.

FIG. 3B shows a top-facing perspective view of a portion of a plug andplay connection system riser joint for a managed pressure drillingsystem in accordance with one or more embodiments of the presentinvention.

FIG. 4A shows a top-facing perspective view of a connection hub ring ofa plug and play connection system for a managed pressure drilling systemin accordance with one or more embodiments of the present invention.

FIG. 4B shows a top plan view of a connection hub ring of a plug andplay connection system for a managed pressure drilling system inaccordance with one or more embodiments of the present invention.

FIG. 4C shows a top-facing perspective view of a ported bottom flange ofa plug and play connection system for a managed pressure drilling systemin accordance with one or more embodiments of the present invention.

FIG. 5 shows an upper marine riser system of a below-tension-ringclosed-loop hydraulic drilling system that includes a plug and playconnection system in accordance with one or more embodiments of thepresent invention.

DETAILED DESCRIPTION OF THE INVENTION

One or more embodiments of the present invention are described in detailwith reference to the accompanying figures. For consistency, likeelements in the various figures are denoted by like reference numerals.In the following detailed description of the present invention, specificdetails are set forth in order to provide a thorough understanding ofthe present invention. In other instances, well-known features to one ofordinary skill in the art are not described to avoid obscuring thedescription of the present invention.

Closed-loop hydraulic drilling systems find application in both onshoreand offshore wells, however, MPD systems are increasingly being used,and in some cases required, in deepwater and ultra-deepwater offshoreapplications including, but not limited to, underbalanced drilling(“UBD”) applications, applied surface backpressure (“ASBP”)-MPD drillingapplications, pressurized mud cap drilling (“PMCD”) applications,floating mud cap drilling (“FMCD”) applications, depleted reservoirdrilling applications, and narrow pressure window drilling applications.

Advantageously, MPD technology may prevent borehole problems includingstuck pipe, lost circulation, and poor wellbore stability. In addition,fewer casings strings and mud weight changes are required. As such, MPDtechnology allows for continuous drilling of longer sections and deeperwells, improving well economics and potentially making marginal, or evenuneconomic, fields profitable to develop. The precise management ofpressure allows for early kick detection, reduces kick volume, minimizeskick loss cycles, and allows for better control of shallow gas and waterflow. In this way, MPD technology improves safety by minimizing blowoutsand other well control situations that are typically encountered in anopen-atmosphere system.

For these reasons, and others, MPD technology is increasingly being usedin offshore applications, especially in deepwater and ultra-deepwaterapplications. However, despite its technical superiority, there has beenresistance to the adoption of MPD technology, such that it is, atpresent, only deployed when absolutely necessary for technical orregulatory reasons or financially worthwhile, a decision that istypically taken prior to drilling and which depends on thecharacteristics of a given well. Although there are costs associatedwith MPD technology, the primary cost hindering wide-scale adoption ofMPD technology relates to the time and labor intensive costs associatedwith installing and removing a group of heavy and lengthy drape hosesthat connect various bottomhole systems and components of the MPD systemto equipment disposed on the platform of the floating drilling rig. Evenwhen MPD systems are deployed, there are substantial costs, includingnon-productive downtime, associated with disconnecting various drapehoses to, for example, service or change a bearing or seal assembly of arotating or active control device respectively. As such, there is along-felt and unsolved need in the industry to simplify the deploymentand operation of MPD systems and to enable the economic retrofitting ofexisting MPD system installations for plug and play operation.

Accordingly, in one or more embodiments of the present invention, a plugand play connection system for a managed pressure drilling systemenables plug and play operation with respect to drape hoses andconnectivity to the MPD system, the subsea blowout preventer (“SSBOP”),and other equipment disposed on or near the subsea surface. The plug andplay connection system allows for the rapid connection or disconnectionof equipment on the floating drilling rig to the MPD system, the SSBOP,or other equipment disposed on or near the subsea surface. Theconnections or disconnections may be made safely, quickly and, easily inadvance.

In one or more embodiments of the present invention, one or more drapehose connections to a connection hub ring of the plug and playconnection system may be made prior to the SSBOP run. Prior to thefloating drilling rig arriving at the location of the well, theconnection hub ring may be installed, hanging attached to the tensionring, in the moon pool area. One or more drape hose connections mayalready connect the connection hub ring to equipment disposed on thefloating drilling rig prior to arrival. After the SSBOP run, the marineriser and MPD system may be installed and the plug and play connectionsystem may be used to facilitate connections and disconnections betweenequipment on the floating drilling rig and the MPD system, the SSBOP, orother equipment disposed on or near the subsea surface. After drillingoperations are completed, the floating drilling rig may then be moved toanother location. Advantageously, all drape hose connections may remainintact during the relocation, expediting the commencement of the nextdrilling operation.

In one or more embodiments of the present invention, once installed,components of the plug and play connection system, as well as componentsof the MPD system itself, may be more easily installed, serviced,pulled, or replaced. In certain embodiments, a plug and play connectionsystem may be deployed as part of an integrated riser joint. In otherembodiments, an existing installation of an upper marine riser systemmay be retrofitted to perform as a plug and play connection system.Advantageously, such embodiments reduce equipment costs, labor costs,and costs associated with non-productive downtime resulting frominstalling, servicing, pulling, or replacing various components of anupper marine riser system or MPD system, including, but not limited to,the telescopic joint, the rotating control device, active controldevice, drill-string isolation tool, flow spool, or components thereof.In all such embodiments, the safety of operations is improved by thecentralized ability to connect or disconnect one or more drape hosesused as part of the MPD system.

FIG. 1 shows an upper marine riser system 100 of a conventionalopen-loop hydraulic drilling system. A floating drilling rig (notindependently illustrated) disposed on a body of water may be used todrill a wellbore (not shown) into the subsea surface (not shown) torecover hydrocarbons (not shown) disposed therein. The floating drillingrig (not independently illustrated) may be a semi-submersible, adrillship (not shown), a drill barge (not shown), or any other type orkind of floating platform or rig that is buoyant and is subjected to theheave of the body of water in which it is disposed. The moon pool area105 of the floating drilling rig (not independently illustrated)provides access to the upper marine riser system 100. The upper marineriser system 100 may include a flow diverter 160 disposed on top of, andin fluid communication with, a flex joint 150. Flex joint 150 may bedisposed on top of, and in fluid communication with, an inner barrel 130of a telescopic joint (e.g., 120, 125, and 130), sometimes referred toas a slip joint. Inner barrel 130 is in fluid connection with an outerbarrel 120 of the telescopic joint (e.g., 120, 125, and 130). Outerbarrel 120 includes a packer 125 disposed at a top distal end that isconfigured to seal an annulus (not shown) between outer barrel 120 andinner barrel 130. Inner barrel 130 is configured to reciprocate withinan inner diameter of outer barrel 120 to accommodate motion of thefloating drilling rig (not independently illustrated) relative to therelatively stationary portion of the upper marine riser system 100disposed below the telescopic joint (e.g., 120, 125, and 130) and marineriser system 110 due to heave of the body of water in which the floatingdrilling rig (not independently illustrated) is disposed.

A tension ring 140 and a plurality of tension cables 145 provide supportto outer barrel 120 of the telescopic joint (e.g., 120, 125, and 130)and any portion of the upper marine riser system 100 and marine risersystem 110 disposed below it. The plurality of tension cables 145connect to tensioners (not shown) disposed on the floating drilling rig(not independently illustrated) and maintain tension as the floatingdrilling rig (not independently illustrated) heaves relative to thecomparatively stationary portion of the upper marine riser system 100disposed below the telescopic joint (e.g., 120, 125, and 130) and marineriser system 110. Outer barrel 120 is in fluid communication with themarine riser system 110 that traverses the water depth and connects to aSSBOP (not shown) disposed at or near the subsea surface (not shown).Marine riser system 110 refers generally to the one or more tubulars orpiping that connects the upper marine riser system 100 to the SSBOP (notshown) or other equipment disposed at or near the subsea surface (notshown).

The SSBOP (not shown) is disposed over, and in fluid communication with,a wellbore (not shown) drilled into the subsea surface (not shown). Acentral lumen, or interior passageway, extends through upper marineriser system 100, marine riser system 110 that traverses the waterdepth, the SSBOP (not shown), and into the wellbore (not shown) tofacilitate drilling operations. A plurality of fixed lines, disposed onan exterior surface of marine riser system 110, connect the SSBOP (notshown) or other equipment (not shown) disposed on or near the subseasurface (not shown) to the telescopic joint (e.g., 120, 125, and 130). Aplurality of drape hoses 170 connect the plurality of fixed lines toequipment disposed on the floating drilling rig (not independentlyillustrated). The fixed lines may include, for example, a kill line, achoke line, a booster line, and a plurality of hydraulic lines. Theplurality of drape hoses 170 are attached below tension ring 140 andinclude sufficient slack to accommodate the heaving motion of thefloating drilling rig (not independently illustrated) relative to thecomparatively stationary portion of the upper marine riser system 100and marine riser system 110.

If the operator wishes to convert the conventional open-loop hydraulicdrilling system depicted in FIG. 1, or similar system, to a closed-loophydraulic drilling system, such as, for example, that depicted in FIG.2, a below-tension-ring MPD system (not shown) is installed betweenouter barrel 120 of the telescopic joint (e.g., 120, 125, and 130) and atop portion of marine riser system 110. Such a conversion requiresremoval of a substantial portion of upper marine riser system 100 in atime-consuming, expensive, and potentially dangerous operation thatresults in substantial non-productive downtime. As such, the decision touse an MPD system (not shown) is usually taken early in the project,prior to deployment of the marine riser system, and operators arereluctant to convert an existing conventional open-loop hydraulicdrilling system once deployed.

FIG. 2 shows an upper marine riser system 200 of a conventionalbelow-tension-ring closed-loop hydraulic drilling system. A floatingdrilling rig (not independently illustrated) may be used to drill awellbore (not shown) into the subsea surface (not shown) to recoverhydrocarbons (not shown) disposed therein. The moon pool area 105 of thefloating drilling rig (not independently illustrated) provides access tothe upper marine riser system 200. Upper marine riser system 200 mayinclude a flow diverter 160 disposed on top of, and in fluidcommunication with, a flex joint 150. Flex joint 150 may be disposed ontop of, and in fluid communication with, an inner barrel 130 of atelescopic joint (e.g., 120, 125, and 130). Inner barrel 130 is in fluidconnection with an outer barrel 120 of the telescopic joint (e.g., 120,125, and 130). Outer barrel 120 includes a packer 125 disposed at a topdistal end that is configured to seal an annulus (not shown) betweenouter barrel 120 and inner barrel 130. Inner barrel 130 is configured toreciprocate within an inner diameter of outer barrel 120 to accommodatemotion of the floating drilling rig (not independently illustrated)relative to the comparatively stationary MPD system (e.g., 210, 220, and230) and marine riser system (e.g., 110 not shown, but disposed below210) due to the heave of the body of water in which the floatingdrilling rig (not independently illustrated) is disposed. A tension ring140 and a plurality of tension cables 145 provide support to outerbarrel 120 of the telescopic joint (e.g., 120, 125, and 130), the MPDsystem (e.g., 210, 220, and 230), and the marine riser system (e.g., 110not shown) disposed below it. The plurality of tension cables 145connect to tensioners (not shown) disposed on the floating drilling rig(not independently illustrated) and maintain tension as the floatingdrilling rig (not independently illustrated) heaves relative to thecomparatively stationary MPD system (e.g., 210, 220, and 230) and marineriser system (e.g., 110 not shown, but disposed below 210).

Outer barrel 120 is in communication with an annular sealing system 230of an MPD system (e.g., 210, 220, and 230). Annular sealing system 230controllably seals the annulus surrounding a drill string (not shown)disposed therethrough. Annular sealing system 230 may be a rotatingcontrol device (not shown), an active control device, or other type ofannular seal (not shown). A relief hose 235 may relieve or providepressure between sealing elements (not shown) of annular sealing system230 or between annular sealing system 230 and drill string isolationtool 220 during, for example, replacement of a sealing element (notshown) of the annular sealing system 230. Annular sealing system 230 iscontrollably in fluid communication with a drill string isolation tool220 that provides an additional annular seal that allows the drillstring (not shown) to be isolated when needed. For example, if annularsealing system 230 requires service, the sealing element (not shown),such as a packer (not shown), of drill string isolation tool 220 may beengaged to maintain the pressure tight seal on the annular, at whichpoint the annular sealing system 230 may be serviced.

Drill string isolation tool 220 is in fluid communication with a flowspool 210 disposed below the annular seal 230 and drill string isolationtool 220. Flow spool 210 includes a plurality of flow spool drape hoses215 that connect to a choke manifold (not shown) disposed on thefloating drilling rig (not independently illustrated). Because theannulus surrounding the drill string (not shown) is sealed pressuretight, wellbore pressure may be controlled by the degree to which one ormore chokes (not shown) of the choke manifold (not shown) are opened orclosed. In this way, wellbore pressure may be precisely maintained at adesired level without requiring the use of varying mud weights. Thechoke manifold (not shown) is typically connected to a mud-gas separator(not shown) or other fluids systems (not shown) disposed on the floatingdrilling rig (not independently illustrated) that are used to removedangerous gas (not shown) from the marine riser system (e.g., 110 notshown).

A marine riser system (e.g., 110 not shown) traverses the water depthand connects flow spool 210 to a SSBOP (not shown) disposed at or nearthe subsea surface (not shown). The marine riser system (e.g., 110 notshown) refers generally to one or more tubulars or piping that connectsthe MPD system (e.g., 210, 220, and 230) to the SSBOP (not shown). TheSSBOP (not shown) is disposed over, and in fluid communication with, awellbore (not shown) drilled into the subsea surface (not shown). Acentral lumen, or interior passageway, extends through upper marineriser system 200, the MPD system (e.g., 210, 220, and 230), the marineriser system (e.g., 110 not shown) that traverses the water depth, theSSBOP (not shown), and into the wellbore (not shown) to facilitatedrilling operations. One of ordinary skill in the art will recognizethat the equipment used to maintain the annular seal and pressurizedfluid return are commonly referred to in the industry as the MPD system(e.g., 210, 220, and 230) and may include one or more of the above-notedcomponents and other components not specifically disclosed, but wellknown in the art.

In addition to relief hose 235 and flow spool drape hoses 215, aplurality of fixed lines, disposed on an exterior surface of the marineriser system (e.g., 110 not shown), connect the SSBOP (not shown) to themarine riser system (e.g., 110 not shown), the MPD system (e.g., 210,220, and 230), and upper marine riser system 200. A plurality of drapehoses 170 connect the plurality of fixed lines to equipment disposed onthe floating drilling rig (not independently illustrated). The fixedlines may include, for example, a kill line, a choke line, a boosterline, and a plurality of hydraulic lines. The plurality of drape hoses170 are connected below tension ring 140 and include sufficient slack toaccommodate the heaving motion of the floating drilling rig (notindependently illustrated) relative to the comparatively stationary MPDsystem (e.g., 210, 220, and 230) and marine riser system riser (e.g.,110 not shown). One or more of the drape hoses 170 or fixed lines may beumbilicals (not shown), used to connect equipment (not shown) disposedon the floating drilling rig (not independently illustrated) to one ormore of annular sealing system 230, drill string isolation tool 220,flow spool 210, or the SSBOP (not shown) or other equipment (not shown)disposed on or near the seafloor. These umbilicals are typically routedoutside of the bottom flange of the telescopic joint (e.g., 120, 125,and 130). When a component of the MPD system (e.g., 210, 220, and 230)requires service, installation, to be pulled, or to be replaced, one ormore drape hoses (e.g., 170, 215, and 235) may have to be disconnectedand then reconnected once the necessary work has been performed. Becausecertain drape hoses (e.g., 215 and 235) may be connected to one or morecomponents of the MPD system (e.g., 210 and 230) disposed underwater,complicated, dangerous, and costly operations must be undertaken toconnect or disconnect them, including potentially, dive or roboticoperations. In addition, there is substantial non-productive downtimewhenever such operations are undertaken.

FIG. 3A shows a cross-sectional view of a plug and play connectionsystem 300 (or a portion of a plug and play connection system 300 riserjoint) for a managed pressure drilling system in accordance with one ormore embodiments of the present invention.

In certain embodiments, a plug and play connection system 300 may beinstalled on an MPD system to facilitate plug and play operation. Plugand play connection system 300 may include a connection hub flange 417disposed around an outer surface of an outer barrel 120 of a telescopicjoint (e.g., 120, 125, and 130). In certain embodiments, connection hubflange 417 may be welded, or otherwise fixedly attached, to outer barrel120. In other embodiments, connection hub flange 417 may be fabricatedas a unitary part of outer barrel 120. Connection hub flange 417 mayinclude a plurality of pass-through ports 440 connected to acorresponding plurality of hub flange ports 450 disposed on a distal endof connection hub flange 417. The plurality of hub flange ports 450 maybe oriented along a longitudinal axis of outer barrel 120 of thetelescopic joint (e.g., 120, 125, and 130).

Plug and play connection system 300 may also include a connection hubring 400 removably disposed around an outer surface of connection hubflange 417. Connection hub ring 400 may include a plurality of dogs 420,substantially disposed in housing 415, that are configured tocontrollably and removably attach connection hub ring 400 to the outersurface of connection hub flange 417. The plurality of dogs 420 may behydraulically or mechanically actuated via a plurality of actuationports 421 that are configured to deploy or retract the plurality of dogs420 into or out of a corresponding receiving profile of connection hubflange 417. As such, connection hub ring 400 may controllably secure orrelease its connection to or from connection hub flange 417. Connectionhub ring 400 may include a plurality of stab-in connectors 430 disposedaround an outer surface (e.g., housing 415) of connection hub ring 400.The plurality of stab-in connectors 430 may be oriented and distributedaround the outer surface of connection hub ring 400 in a manner suitablefor a particular application or design. As such, one of ordinary skillin the art will recognize that the number of stab-in connectors 430, aswell as their type, kind, size, shape, orientation, and distribution mayvary based on an application or design in accordance with one or moreembodiments of the present invention.

Plug and play connection system 300 may also include a bearing ring 410configured to movably attach connection hub ring 400 to a tension ring140 that supports a packer 125 of the telescopic joint (e.g., 120, 125,and 130). A first side of bearing ring 410 may be welded, or otherwisefixedly attached, to a bottom side of tension ring 140 and a second sideof bearing ring 410 may be welded, or otherwise fixedly attached, to atop side of connection hub ring 400. Bearing ring 410 may be configuredto allow for rotational movement between tension ring 140 and connectionhub ring 400. During installation and removal, the freedom of rotationalmovement helps achieve proper alignment of connection hub ring 400 withconnection hub flange 417 such that the stab-in connectors 430 ofconnection hub ring 400 may be aligned with their correspondingpass-through ports 440 of connection hub flange 417 for communication.

Plug and play connection system 300 may also include a ported bottomflange 500 connected to a bottom distal end of outer barrel 120. Portedbottom flange 500 may include a plurality of bottom flange ports (notshown) that traverse ported bottom flange 500 for further plug and playconnectivity, directly or indirectly, to corresponding connections (notshown) of, for example, an annular sealing system (not shown) or othercomponent of an MPD system (not shown) disposed directly below it. Theannular sealing system (not shown) may include a modified top flange(not shown) configured to mate with the bottom flange ports (not shown)of ported bottom flange 500 to facilitate plug and play operation.

Plug and play connection system 300 may also include a plurality ofconduits 330 that connect the plurality of connection hub flange ports450 to the corresponding plurality of bottom flange ports (not shown).The plurality of stab-in connectors 430 may connect to the plurality ofconnection hub flange ports 450 by way of the plurality of pass-throughports 440 within connection hub flange 417.

Plug and play connection system 300 may also include a plurality ofdrape hoses (not shown), each of which has a first distal end connectedto a stab-in connector (e.g., 430) and a second distal end connected toa device or system (not shown) disposed on a platform (not shown) of thefloating rig (not shown). The plurality of stab-in connectors 430,pass-through ports 440, hub flange ports 450, conduits 330, and bottomflange ports (not shown) form a plurality of communication lines (notindependently illustrated) that may be used to connect one or more fluidlines, hydraulic lines, umbilicals, or combinations thereof. Because theplurality of stab-in connectors 430 are disposed around connection hubring 400, all connections between equipment disposed on the platform(not shown) of the drilling rig (not shown) may be safely and easilymade or removed, as needed, in the moon pool area (e.g., 105 of FIG. 5).Notwithstanding the above, such connections may be made in advance ofdeployment of the plug and play connection system 300 as part of the MPDsystem (not shown), but in such instances, connections anddisconnections may be made, as needed, in the moon pool area (e.g., 105of FIG. 5).

In other embodiments, a plug and play connection system 300 may beconfigured as a riser joint for rapid installation, service, and removaland to facilitate plug and play operation. Plug and play connectionsystem 300 riser joint may include a top flange (not shown) attached toa top distal end of inner barrel 130. The top flange (not shown) may beused to connect the riser joint to equipment disposed above it in theupper marine riser system (not shown), including, for example, a flexjoint (e.g., 150). Inner barrel 130 may include an inner barrel centrallumen 132, or interior passageway, having a first diameter, throughwhich the drill string or other equipment (not shown) may be removablydisposed. Outer barrel 120 may include an outer barrel central lumen 122having a second diameter larger than the inner barrel 130. Inner barrel130 may be configured to reciprocate, in a telescoping manner, withinouter barrel 120, such that the inner barrel central lumen 132 remainsin fluid communication with the outer barrel central lumen 122regardless of the extent to which inner barrel 130 is displaced withinouter barrel 120 due to heave. A packer 125 may be disposed at or near atop distal end of outer barrel 120 that is configured to seal an annulusbetween inner barrel 130 and outer barrel 120 of the telescopic joint(e.g., 120, 125, and 130) as the inner barrel 130 reciprocates.Specifically, packer 125 may include a plurality of seals 127 that sealthe annulus between inner barrel 130 and outer barrel 120 as innerbarrel 130 reciprocates within outer barrel 120. A tension ring 140 maybe disposed around, and supports or is secured to, an outer surface ofpacker 125. Tension ring 140 may have a profile configured to cradle andsupport packer 125 to support the weight of the equipment disposed belowit.

Plug and play connection system 300 riser joint may also include aconnection hub flange 417 disposed around an outer surface of outerbarrel 120 of the telescopic joint (e.g., 120, 125, and 130). In certainembodiments, connection hub flange 417 may be welded, or otherwisefixedly attached, to outer barrel 120. In other embodiments, connectionhub flange 417 may be fabricated as a unitary part of outer barrel 120.Connection hub flange 417 may include a plurality of pass-through ports440 connected to a corresponding plurality of hub flange ports 450disposed on a distal end of connection hub flange 417. The plurality ofhub flange ports 450 may be oriented along a longitudinal axis of outerbarrel 120 of the telescopic joint (e.g., 120, 125, and 130).

Plug and play connection system 300 riser joint may also include aconnection hub ring 400 removably disposed around an outer surface ofconnection hub flange 417. Connection hub ring 400 may include aplurality of dogs 420, substantially disposed in housing 415, that areconfigured to controllably and removably attach connection hub ring 400to the outer surface of connection hub flange 417. The plurality of dogs420 may be hydraulically or mechanically actuated via a plurality ofactuation ports 421 that are configured to deploy or retract theplurality of dogs 420 into or out of a corresponding receiving profileof connection hub flange 417. As such, connection hub ring 400 maycontrollably secure or release its connection to or from connection hubflange 417. Connection hub ring 400 may include a plurality of stab-inconnectors 430 disposed around an outer surface (e.g., housing 415) ofconnection hub ring 400. The plurality of stab-in connectors 430 may beoriented and distributed around the outer surface of connection hub ring400 in a manner suitable for a particular application or design. Assuch, one of ordinary skill in the art will recognize that the number ofstab-in connectors 430, as well as their type, kind, size, shape,orientation, and distribution may vary based on an application or designin accordance with one or more embodiments of the present invention.

Plug and play connection system 300 riser joint may also include abearing ring 410 configured to movably attach connection hub ring 400 totension ring 140 that supports a packer 125 of the telescopic joint(e.g., 120, 125, and 130). A first side of bearing ring 410 may bewelded, or otherwise fixedly attached, to a bottom side of tension ring140 and a second side of bearing ring 410 may be welded, or otherwisefixedly attached, to a top side of connection hub ring 400. Bearing ring410 may be configured to allow for rotational movement between tensionring 140 and connection hub ring 400. During installation and removal,the freedom of rotational movement helps achieve proper alignment ofconnection hub ring 400 with connection hub flange 417 such that thestab-in connectors 430 of connection hub ring 400 may be aligned withtheir corresponding pass-through ports 440 of connection hub flange 417for communication.

Plug and play connection system 300 riser joint may also include aported bottom flange 500 connected to a bottom distal end of outerbarrel 120. Ported bottom flange 500 may include a plurality of bottomflange ports (not shown) that traverse ported bottom flange 500 forfurther plug and play connectivity, directly or indirectly, tocorresponding connections (not shown) of, for example, an annularsealing system (not shown) or other component of an MPD system (notshown) disposed directly below it. The annular sealing system (notshown) may include a modified top flange (not shown) configured to matewith the bottom flange ports (not shown) of ported bottom flange 500 tofacilitate plug and play operation.

Plug and play connection system 300 riser joint may also include aplurality of conduits 330 that may connect the plurality of connectionhub flange ports 450 to the corresponding plurality of bottom flangeports (not shown). The plurality of stab-in connectors may connect tothe plurality of connection hub flange ports 450 by way of the pluralityof pass-through ports 440 within connection hub flange 417.

Plug and play connection system 300 riser joint may also include aplurality of drape hoses (not shown), each of which has a first distalend connected to a stab-in connector (e.g., 430) and a second distal endconnected to a device or system (not shown) disposed on a platform (notshown) of the floating rig (not shown). The plurality of stab-inconnectors 430, pass-through ports 440, hub flange ports 450, conduits330, and bottom flange ports (not shown) form a plurality ofcommunication lines (not independently illustrated) that may be used toconnect one or more fluid lines, hydraulic lines, umbilicals, orcombinations thereof. Because the plurality of stab-in connectors 430are disposed around connection hub ring 400, all connections betweenequipment disposed on the platform (not shown) of the drilling rig (notshown) may be safely and easily made or removed, as needed, in the moonpool area (e.g., 105 of FIG. 5). Notwithstanding the above, suchconnections may be made in advance of deployment of the plug and playconnection system 300 as part of the MPD system (not shown), but in suchinstances, connections and disconnections may be made, as needed, in themoon pool area (e.g., 105 of FIG. 5).

In still other embodiments, a plug and play connection system 300 may beinstalled on an MPD system (not shown) in the field to facilitate plugand play operation. The floating drilling rig (not shown) is typicallyfloating on the sea and positioned over the wellbore. Typically, tensionring 140 is already in place in the moon pool area (not shown) under therotary table. Connection hub ring 400 may, by way of bearing ring 410,be fixedly attached to tension ring 140. The plurality of drape hoses(not shown), potentially including one or more umbilicals, may connectequipment (not shown) disposed on the floating drilling rig (not shown)to the plurality of stab-in connectors 430 of connection hub ring 400.The SSBOP (not shown) may be positioned under tension ring 140 andconnection hub ring 400, all aligned with the rotary table (not shown).The marine riser (not shown) may be deployed through the rotary table(not shown), tension ring 140, and connection hub ring 400 and may beconnected to the lower flex joint (not shown) at the top of the SSBOP(not shown). The SSBOP (not shown) run may start as other marine riser(not shown) segments are successively connected one after the other andthe SSBOP (not shown) is directed down toward the subsea wellbore. Theriser-gas-handling, or MPD, system (e.g., 210, 220, and 230 of FIG. 2)may be connected to the marine riser system (not shown) when the SSBOP(not shown) is near the wellbore. The telescopic joint (e.g., 120, 125,and 130), specifically, ported bottom flange 500 of outer barrel 120,may be connected, directly or indirectly, to the top most component ofthe riser gas handling, or MPD, system (e.g., 210, 220, and 230 of FIG.2). All lines (e.g., 330) and umbilicals (e.g., 330) may be set as fixedlines pre-connected to the MPD system (e.g., 210, 220, and 230 of FIG.2) and run up fixed to a top most flange of the MPD system (e.g., 210,220, and 230 of FIG. 2), such as, for example, a custom top flange (notshown) of the annular sealing system (e.g., 230 of FIG. 2) configured tocommunicate with ported bottom flange 500 of plug and play connectionsystem 300. The telescopic joint (e.g., 120, 125, and 130) may berotated to align all auxiliary lines such as, for example, kill line,choke line, or booster line, to connection hub ring 400 before packer125 of outer barrel 120 of the telescopic joint (e.g., 120, 125, and130) comes to rest on tension ring 140. This horizontal alignment may beachieved using the kill and choke lines as a reference, while the clockof the other lines may vary based on an application or design. Thevertical alignment is warranted when the telescopic joint (e.g., 120,125, and 130) rests on tension ring 140 by the vertical measure of theequipment. Once the lines, by way of pass-through ports 440, are alignedwith their stab-in connectors 430, the dogs (not shown) of thetelescopic joint (e.g., 120, 125, and 130) are hydraulically orotherwise actuated to lock the telescopic joint (e.g., 120, 125, and130) to tension ring 140. Then the plurality of dogs 420 of connectionhub ring 400 may be hydraulically or otherwise actuated to secureconnection hub ring 400 to connection hub flange 417 that is fixedlyattached to outer barrel 120 of the telescopic joint (e.g., 120, 125,and 130). As such, the fixed lines of the telescopic joint (e.g., 120,125, and 130) are aligned and thus ready for connection by way ofstab-in connectors 430 of connection hub ring 400. The stab-inconnectors 430 may be hydraulically or otherwise activated with at leastdouble sealing redundancies. The fixed lines from the SSBOP (not shown)and the MPD system (e.g., 210, 220, and 230 of FIG. 2) are then readyfor testing before the SSBOP (not shown) is attached to the wellhead(not shown).

Continuing, FIG. 3B shows a top-facing perspective view of a portion ofa plug and play connection system 300 riser joint for managed pressuredrilling system in accordance with one or more embodiments of thepresent invention. In this perspective view, the distribution of theplurality of stab-in connectors 430 around housing 415 of connection hubring 400 (of one exemplary embodiment) is shown. One of ordinary skillin the art will recognize that the number of stab-in connectors 430, aswell as their type, kind, size, shape, orientation, and distribution mayvary based on an application or design in accordance with one or moreembodiments of the present invention. Each stab-in connector 430 mayconnect via a corresponding pass-through port 440, disposed within theconnection hub flange (not independently illustrated) of outer barrel120, to a corresponding plurality of hub flange ports (e.g., 450 of FIG.3A) disposed on a distal end of the connection hub flange. Each hub port(e.g., 450 of FIG. 3A) may connect via a corresponding conduit 330 to acorresponding bottom flange port (not independently illustrated) ofported bottom flange 500. The plurality of bottom flange ports (notindependently illustrated) may traverse ported bottom flange 500 forconnection to the equipment disposed below ported bottom flange 500 inthe MPD system (not shown) or marine riser system (not shown). One ofordinary skill in the art will recognize that top flange 340 may includea clock of ports that allow for the routing of lines and umbilicalsoriginating from the SSBOP (not shown) or MPD system (not shown) asneeded based on a particular application or design.

FIG. 4A shows a top-facing perspective view of a connection hub ring 400and bearing ring 410 of a plug and play connection system (e.g., 300 ofFIG. 3) for a managed pressure drilling system in accordance with one ormore embodiments of the present invention. A plug and play connectionsystem (e.g., 300 of FIG. 3) may include a connection hub ring 400, aconnection hub flange (e.g., 417 of FIG. 3A), a ported bottom flange(e.g., 500 of FIG. 4C), and a plurality of conduits (e.g., 330 of FIG.3B) that connect the plurality of hub flange ports (not shown) of theconnection hub flange (e.g., 417 of FIG. 3A) to the plurality of bottomflange ports (not shown) of the ported bottom flange (e.g., 500 of FIG.4C). The plurality of bottom flange ports (not shown) may be used toconnect the plug and play connection system (e.g., 300 of FIG. 3) toequipment disposed below the telescopic joint (not shown).

As previously discussed, a bearing ring 410 may be fixedly attached to atop side of connection hub ring 400 and a bottom side of a tension ring(e.g., 140 of FIG. 3A). A first side of bearing ring 410 may be welded,or otherwise fixedly attached, to a bottom side of tension ring 140 anda second side of bearing ring 410 may be welded, or otherwise fixedlyattached, to a top side of connection hub ring 400. Bearing ring 410 maybe configured to allow for rotational movement between tension ring 140and connection hub ring 400.

Connection hub ring 400 may include a plurality of dogs (e.g., 420 ofFIG. 3A), substantially disposed in housing 415, that may be configuredto controllably attach connection hub ring 400 to the outer surface ofthe connection hub flange (e.g., 417 of FIG. 3A). The plurality of dogs(e.g., 420 of FIG. 3A) may be hydraulically or mechanically actuated viaa plurality of actuation ports 421 that are configured to deploy orretract the plurality of dogs (e.g., 420 of FIG. 3A) into or out of acorresponding receiving profile of the connection hub flange (e.g., 417of FIG. 3A). As such, connection hub ring 400 may controllably secure orrelease its connection to or from the connection hub flange (e.g., 417of FIG. 3A).

Connection hub ring 400 may also include a plurality of stab-inconnectors 430 disposed around an outer surface (e.g., housing 415) ofconnection hub ring 400. The plurality of stab-in connectors 430 may beoriented and distributed around the outer surface of connection hub ring400 in a manner suitable for a particular application or design. Assuch, one of ordinary skill in the art will recognize that the number ofstab-in connectors 430, as well as their type, kind, size, shape,orientation, and distribution may vary based on an application or designin accordance with one or more embodiments of the present invention.

Continuing, FIG. 4B shows a top plan view of connection hub ring 400 ofthe plug and play connection system (e.g., 300 of FIG. 3) for a managedpressure drilling system in accordance with one or more embodiments ofthe present invention. In this view, a distribution of stab-inconnectors 430 and dog-actuated ports 421 are shown as being evenlyspaced about the outer diameter of connection hub ring 400. However, oneof ordinary skill in the art will recognize that the number of stab-inconnectors 430 and dog actuation ports 421, as well as their type, kind,size, shape, orientation, and distribution may vary based on anapplication or design in accordance with one or more embodiments of thepresent invention. Additionally, one of ordinary skill in the art willalso recognize that the inner diameter, ID, may vary based on anapplication or design in accordance with one or more embodiments of thepresent invention.

Continuing, FIG. 4C shows a top-facing perspective view of a portedbottom flange 500 of a plug and play connection system (e.g., 300 ofFIG. 3) for a managed pressure drilling system in accordance with one ormore embodiments of the present invention. In one or more embodiments ofthe present invention, ported bottom flange 500 may include a pluralityof bottom flange ports (e.g., 510, 520, and 530) that traverse and passthrough ported bottom flange 500. The plurality of bottom flange ports510 a, 510 b, 510 c, 510 d, and 510 e may include one or more of a chokeline, a kill line, a booster line, and one or more hydraulic lines thatultimately connect to the SSBOP (not shown). The plurality of bottomflange ports 520 a, 520 b, 520 c, 520 d, and 520 e may include one ormore relief lines, lubrication lines, flow diverter lines, circulationlines, and other hydraulic lines. The plurality of bottom flange ports530 a and 530 b may be one or more umbilical connection ports for one ormore of a bearing umbilical, a rotating control device umbilical, anactive control device umbilical, a control umbilical, a valve umbilical,or any other type or kind of umbilical that may need to traverse themarine riser system (not shown).

The plurality of bottom flange ports (e.g., 510, 520, and 530) of portedbottom flange 500 may be configured for plug and play connection,directly or indirectly, to the corresponding connections (not shown) ofan annular sealing system (not shown), or other device, disposeddirectly below it. One or more of the bottom flange ports (e.g., 510,520, and 530) of ported bottom flange 500 may connect to one or more ofa choke line, a kill line, a booster line, and one or more hydrauliclines of the SSBOP (not shown) or other equipment disposed at or nearthe subsea surface of a wellbore (not shown). One or more of the bottomflange ports (e.g., 510, 520, and 530) of ported bottom flange 500 mayconnect to one or more relief lines, lubricating lines, flow diverterlines, circulation lines, and other hydraulic lines. One or more of thebottom flange ports (e.g., 510, 520, and 530) of ported bottom flange500 may connect to one or more of a bearing umbilical, a rotatingcontrol device umbilical, an active control device umbilical, a controlumbilical, a valve umbilical, or any other type or kind of umbilicalthat may traverse the marine riser system (not shown). The annularsealing system (not shown) may include a modified top flange (not shown)configured to mate with the bottom flange ports (e.g., 510, 520, and530) of ported bottom flange 500 when connected together for plug andplay operation.

One of ordinary skill in the art will recognize that the type, kind,size, shape, and number, as well as the clock orientation, of bottomflange ports may vary based on an application or design in accordancewith one or more embodiments in the present invention.

FIG. 5 shows an upper marine riser system 600 of a below-tension-ringclosed-loop hydraulic drilling system that includes a plug and playconnection system in accordance with one or more embodiments of thepresent invention. A floating drilling rig (not independentlyillustrated) may be used to drill a wellbore (not shown) into the subseasurface (not shown) to recover hydrocarbons (not shown) disposedtherein. The moon pool area 105 of the floating drilling rig (notindependently illustrated) may provide access to the upper marine risersystem 600. The upper marine riser system 600 may include a flowdiverter 160 disposed on top of, and in fluid communication with, a flexjoint 150. Flex joint 150 may be disposed on top of, and in fluidcommunication with, an inner barrel 130 of a telescopic joint (e.g.,120, 125, and 130). Inner barrel 130 may be in fluid connection with anouter barrel 120 of the telescopic joint. Inner barrel 130 may beconfigured to reciprocate within an inner diameter of an outer barrel120 to accommodate motion of the floating drilling rig (notindependently illustrated) relative to the comparatively stationary MPDsystem (e.g., 210, 220, and 230) and marine riser system (e.g., 110 notshown) due to the heave of the body of water in which the floatingdrilling rig (not independently illustrated) is deployed. A tension ring140 and a plurality of tension cables 145 may provide support to outerbarrel 120 of the telescopic joint (e.g., 120, 125, and 130) and otherequipment disposed below it. The plurality of tension cables 145 mayconnect to tensioners (not shown) disposed on the floating drilling rig(not independently illustrated) and maintain tension as the floatingdrilling rig (not independently illustrated) heaves relative to thecomparatively stationary MPD system (e.g., 210, 220, and 230) and marineriser system (e.g., 110 not shown).

The outer barrel 120 may be in communication with an annular sealingsystem 230. Annular sealing system 230 may seal the annulus surroundinga drill string (not shown) disposed therethrough. Annular sealing system230 may be a rotating control device (not shown), an active controldevice, or other type of annular seal (not shown). Annular sealingsystem 230 may controllably be in fluid communication with a drillstring isolation tool 220 that provides an additional annular seal thatallows the drill string (not shown) to be isolated when needed. Forexample, if annular sealing system 230 requires service, the sealingelement (not shown) of drill string isolation tool 220 may be engaged tomaintain the pressure tight seal on the annular. Drill string isolationtool 220 may be in fluid communication with a flow spool 210 disposedbelow the annular seal.

A marine riser system (e.g., 110 not shown) that traverses the waterdepth may connect flow spool 210 to a SSBOP (not shown) disposed at ornear the subsea surface. The marine riser system (e.g., 110 not shown)may refer generally to the one or more tubulars or piping that connectsthe MPD system 210, 220, and 230 to the SSBOP (not shown). The SSBOP(not shown) may be disposed over, and in fluid communication with, awellbore (not shown) drilled into the subsea surface (not shown). Acentral lumen, or interior passageway, extends through upper marineriser system 600, MPD system 210, 220, and 230, the marine riser system(e.g., 110 not shown) that traverses the water depth, the SSBOP (notshown), and into the wellbore (not shown) to facilitate drillingoperations. One of ordinary skill in the art will recognize that theequipment used to maintain the annular seal and pressurized fluid returnare commonly referred to in the industry as the MPD system and mayinclude one or more of the above-noted components (e.g., 210, 220, and230) and other components not specifically disclosed.

A plurality of fixed lines, disposed on an exterior surface of themarine riser system (e.g., 110 not shown), connect the SSBOP (not shown)to the marine riser (e.g., 110 not shown), MPD system 210, 220, 230, andpotentially upper marine riser system 600. A plurality of drape hoses170 connect, by way of the connection hub ring 400, the plurality offixed lines to equipment disposed on the floating drilling rig (notindependently illustrated). The fixed lines may include, for example, akill line, a choke line, a booster line, and a plurality of hydrauliclines. A plurality of flow spool drape hoses 215 divert, by way of theconnection hub ring 400, returning annular fluids to a choke manifold(not shown) disposed on the floating drilling rig (not independentlyillustrated). Because the annulus surrounding the drill string (notshown) is sealed pressure tight, wellbore pressure may be controlled bythe degree to which one or more chokes (not shown) of the choke manifold(not shown) are opened or closed. In this way, wellbore pressure may beprecisely maintained at a desired level without requiring the use ofvarying mud weights. The choke manifold (not shown) is typicallyconnected to a mud-gas separator and other fluids systems on thefloating drilling rig (not shown) that are used to remove dangerous gasfrom the marine riser system (e.g., 110 not shown). One or more reliefhoses 235 may fluidly connect, by way of connection hub ring 400,relieve or provide pressure between sealing elements (not shown) ofannular sealing system 230 or between annular sealing system 230 anddrill string isolation tool 220 during, for example, replacement of asealing element (not shown) of the annular sealing system 230. Theplurality of drape hoses 170, 215, and 235 all connect to the plug andplay connection system via connection hub ring 400 and includesufficient slack to accommodate the heaving motion of the floatingdrilling rig (not independently illustrated) relative to thecomparatively stationary MPD system 210, 220, 230 and marine risersystem riser (e.g., 110 not shown). In addition, one or more drape hoses170 may comprise umbilicals (not shown) that may be used to connect toone or more of annular sealing system 230, drill string isolation tool220, flow spool 210, or the SSBOP (not shown) to equipment disposed onthe floating drilling rig (not independently illustrated).

When a component of the MPD system 210, 220, 230 requires service,installation, to be pulled, or to be replaced, one or more drape hoses170, 215, and 235 may be easily disconnected from connection hub ring400 and then reconnected to connection hub ring 400 once the necessarywork has been performed. Because all drape hoses 170, 215, and 235connect via connection hub ring 400, they may be easily connected anddisconnected in the moon pool area 105 of the floating drilling rig (notindependently illustrated), substantially reducing the amount of timerequired, the costs associated with, including non-productive downtime,of undertaking such actions as well as increasing the safety ofoperations. In this way, the plug and play connection system providestrue plug and play operation, fully integrating the MPD system with themarine riser system and providing intuitive and efficient connectivity.

A method of configuring a managed pressure drilling system for use witha plug and play connection system may include attaching a connection hubflange to an outer barrel of a telescopic joint. A ported bottom flangemay be attached to a bottom portion of the telescopic joint. A pluralityof hub flange ports of the connection hub ring may connect to aplurality of bottom flange ports of the ported bottom flange with aplurality of conduits. A first side of a bearing ring may attach to abottom side of a tension ring. A second side of the bearing ring mayattach to a top side of a connection hub ring. The tension ring, bearingring, and connection hub ring, now attached, may be disposed around thetelescopic joint below a packer of the telescopic joint. The marineriser and MPD system may be run through the tension ring, bearing ring,and connection hub ring during installation. A plurality of drape hosesmay connect a plurality of stab-in connectors of the connection hub ringto equipment disposed on a platform of the floating drilling rig. Onceinstalled, the plurality of stab-in connectors may be hydraulicallyactuated to enable their fluid or other communication operations.

Advantages of one or more embodiments of the present invention mayinclude one or more of the following:

In one or more embodiments of the present invention, a plug and playconnection system provides for the plug and play operation of an MPDsystem with respect to drape hoses, which may be easily, efficiently,and safely connected or disconnected via the connection hub ring.

In one or more embodiments of the present invention, a plug and playconnection system allows for the rapid connection or disconnection ofequipment on the drilling rig to the MPD system and the SSBOP or otherequipment disposed on or near the subsea floor via the connection hubring. The drape hoses may be easily, efficiently, and safely connectedor disconnected via the connection hub ring.

In one or more embodiments of the present invention, a plug and playconnection system allows for the rapid connection or disconnection ofequipment as part of the upper marine riser system including thetelescopic joint, rotating control device, active control device, flowspool, or replaceable components thereof. Because the plug and playconnection system allows for the rapid disconnection of the drape hosesfrom the equipment on the drilling rig to the MPD system and the SSBOPor other equipment disposed on or near the subsea floor, the equipmentof the MPD system may be serviced, installed, pulled, or replaced moreeasily. Once the necessary work has been performed, the plug and playconnection system allows for the rapid connection of the equipment onthe drilling rig to the MPD system, SSBOP, or other equipment faster andmore efficiently than a conventional MPD system.

In one or more embodiments of the present invention, a plug and playconnection system allows for the rapid connection to the fixed lines ofthe SSBOP, replacing any conventional KT rings, directly receiving thefixed lines from the MPD system while shortening the flexible lines forthe circulation and control of the MPD system from the rig structure.

In one or more embodiments of the present invention, the drape hoses maybe pre-connected to the connection hub ring of the plug and playconnection system, reducing or eliminating the time and cost associated,and then hydraulically actuated once installed.

In one or more embodiments of the present invention, a plug and playconnection system reduces non-productive time and associated costsrelating to servicing, installing, pulling, or replacing components ofthe MPD system, SSBOP, or other equipment than a conventional MPDsystem.

In one or more embodiments of the present invention, a plug and playconnection system reduces the amount of time required to, and costsassociated with, servicing, installing pulling, or replacing variouscomponents of the upper marine riser system, including the telescopicjoint, as well as rotating control devices, active control devices, flowspools, or replaceable components thereof than a conventional telescopicjoint and MPD system.

While the present invention has been described with respect to theabove-noted embodiments, those skilled in the art, having the benefit ofthis disclosure, will recognize that other embodiments may be devisedthat are within the scope of the invention as disclosed herein.Accordingly, the scope of the invention should be limited only by theappended claims.

What is claimed is:
 1. A connection system for a managed pressuredrilling system comprising: a connection hub flange comprising aplurality of pass-through ports and a plurality of connection hub flangeports; a connection hub ring removably disposed around an outer surfaceof the connection hub flange, the connection hub ring comprising: aplurality of dogs configured to removably attach the connection hub ringto the outer surface of the connection hub flange, and a plurality ofstab-in connectors disposed around an outer surface of the connectionhub ring; a ported bottom flange comprising a plurality of bottom flangeports; and a plurality of conduits that connect the plurality ofconnection hub flange ports to the plurality of bottom flange ports,wherein the plurality of stab-in connectors are connected to theplurality of connection hub flange ports by the plurality ofpass-through ports.
 2. The connection system of claim 1, furthercomprising: a bearing ring configured to movably attach the connectionhub ring to a tension ring configured to support a packer of the outerbarrel of the telescopic joint.
 3. The connection system of claim 1,further comprising: a plurality of drape hoses, wherein each drape hosehas a first distal end connected to a stab-in connector from theplurality of stab-in connectors and a second distal end connected to adevice or system disposed on a platform of a floating rig.
 4. Theconnection system of claim 1, wherein the ported bottom flange isconfigured to connect, directly or indirectly, to an annular sealingsystem disposed below it as part of a marine riser.
 5. The connectionsystem of claim 1, wherein the plurality of bottom flange ports connectto one or more of a choke line, a kill line, a booster line, and ahydraulic line of a subsea blowout preventer disposed at or near asubsea surface of a wellbore.
 6. The connection system of claim 1,wherein the plurality of bottom flange ports connect to one or more of acirculation line and a relief line.
 7. The connection system of claim 1,wherein the plurality of bottom flange ports connect to one or more of abearing umbilical, a rotating control device umbilical, an activecontrol device umbilical, a control umbilical, a valve umbilical, orother umbilical.
 8. A connection system riser joint for a managedpressure drilling system comprising: an inner barrel configured toreciprocate within an outer barrel; a packer disposed at a top distalend of the outer barrel; a tension ring configured to support thepacker; a connection hub flange comprising a plurality of pass-throughports and a plurality of hub flange ports; a connection hub ringremovably disposed around an outer surface of the connection hub flange,the connection hub ring comprising: a plurality of dogs configured toremovably attach the connection hub ring to the outer surface of theconnection hub flange, and a plurality of stab-in connectors disposedaround an outer surface of the connection hub ring; a bearing ringconfigured to movably attach the connection hub ring to the tensionring; a ported bottom flange connected to the bottom distal end of theouter barrel, the ported bottom flange comprising a plurality of bottomflange ports; and a plurality of conduits that connect the plurality ofconnection hub flange ports to the plurality of bottom flange ports,wherein the plurality of stab-in connectors are connected to theplurality of connection hub flange ports by the plurality ofpass-through ports.
 9. The connection system riser joint of claim 8,further comprising: a top flange attached to a top distal end of theinner barrel.
 10. The connection system riser joint of claim 8, furthercomprising: a plurality of drape hoses, wherein each drape hose has afirst distal end connected to a stab-in connector from the plurality ofstab-in connectors and a second distal end connected to a device orsystem disposed on a platform of a floating rig.
 11. The connectionsystem riser joint of claim 8, wherein the packer comprises a pluralityof seals.
 12. The connection system riser joint of claim 8, wherein theported bottom flange is configured to connect directly or indirectly toan annular sealing system of a marine riser.
 13. The connection systemriser joint of claim 8, wherein a top side of the connection hub ring isattached to a first side of the bearing ring and a second side of thebearing ring is attached to a bottom side of the tension ring.
 14. Theconnection system riser joint of claim 8, wherein the connection hubring, the plurality of drape hoses, and the plurality of conduits arepreinstalled before installation of the managed pressure drillingsystem.
 15. The connection system riser joint of claim 8, wherein theplurality of bottom flange ports connect to one or more of a choke line,a kill line, a booster line, and a hydraulic line of a subsea blowoutpreventer disposed at or near a subsea surface of a wellbore.
 16. Theconnection system riser joint of claim 8, wherein the plurality ofbottom flange ports connect to one or more of a circulation line and arelief line.
 17. The connection system riser joint of claim 8, whereinthe plurality of bottom flange ports connect to one or more of a bearingumbilical, a rotating control device umbilical, an active control deviceumbilical, a control umbilical, a valve umbilical, or other umbilical.18. A method of retrofitting a managed pressure drilling system for usewith a connection system comprising: attaching a connection hub flangeto an outer barrel of a telescopic joint; attaching a ported bottomflange to a bottom portion of the telescopic joint; connecting aplurality of hub flange ports of the connection hub flange to aplurality of bottom flange ports of the ported bottom flange with aplurality of conduits; attaching a first side of a bearing ring to abottom side of a tension ring; attaching a second side of the bearingring to a top side of a connection hub ring; and disposing the tensionring, bearing ring, and connection hub ring around the telescopic jointbelow a packer of the telescopic joint.